Fabrications and Applications of Micro/nanofluidics in Oil and Gas Recovery: A Comprehensive Review

Understanding fluid flow characteristics in porous medium, which determines the development of oil and gas oilfields, has been a significant research subject for decades. Although using core samples is still essential, micro/nanofluidics have been attracting increasing attention in oil recovery fields since it offers direct visualization and quantification of fluid flow at the pore level. This work provides the latest techniques and development history of micro/nanofluidics in oil and gas recovery by summarizing and discussing the fabrication methods, materials and corresponding applications. Compared with other reviews of micro/nanofluidics, this comprehensive review is in the perspective of solving specific issues in oil and gas industry, including fluid characterization, multiphase fluid flow, enhanced oil recovery mechanisms, and fluid flow in nano-scale porous media of unconventional reservoirs, by covering most of the representative visible studies using micro/nanomodels. Finally, we present the challenges of applying micro/nanomodels and future research directions based on the work

A Comprehensive Review of Experimental Evaluation Methods and Results of Polymer Micro/nanogels for Enhanced Oil Recovery and Reduced Water Production

In recent years, polymer micro/nanogels which are re-crosslinked polymers with 3D networks, have attracted a lot of interest in Enhanced Oil Recovery (EOR) field. In size of micro/nanometers, these gel particles are designed to be conformance control agents for in-depth fluid diversion, and various experimental research have been undertaken to investigate the possibilities of applying micro/nanogels in oilfield. However, it is still unclear that how to utilize micro/nanogels to their full potential in oilfield because the transport mechanisms and EOR mechanisms of micro/nanogels are not well studied currently. By reviewing experimental evaluations and corresponding results of micro/nanogels, including evaluation of particle physiochemical properties, transport, and potential EOR mechanisms, the review aims to discuss the evaluation of micro/nanogel particles, transport issue in many experimental designs and the debates of EOR mechanisms. Finally, we present the current challenges of micro/nanogels application and recommend the future research directions based on the review

Laboratory Evaluation of a Novel Self-Healable Polymer Gel for CO2 Leakage Remediation during CO2 Storage and CO2 Flooding

For CO2 storage in subsurface reservoirs, one of the most crucial requirements is the ability to remediate the leakage caused by the natural fractures or newly generated fractures due to the increasing pore pressure associated with CO2 injection. For CO2 Enhanced Oil Recovery (EOR), high conductivity features such as fractures and void space conduits can severely restrict the CO2 sweep efficiency. Polymer gels have been developed to plug the leakage and improve the sweep efficiency. This work evaluated a CO2 resistant branched self-healable preformed particle gel (CO2-BRPPG) for CO2 plugging purpose. This novel CO2-BRPPG can reform a mechanical robust adhesive bulk gel after being placed in the reservoir and efficiently seal fractures. In this work, the swelling kinetics, self-healing behavior, thermal stability, CO2 stability, rheology, adhesion property and plugging performance of this novel CO2-BRPPG were studied in the laboratory. Results showed that this CO2-BRPPG has good self-healing abilities, and the self-healed bulk gel has excellent mechanical and adhesion strength. Gel with a swelling ratio of ten has an elastic modulus of over 2000 Pa, and the adhesion strength to sandstone is 1.16 psi. The CO2-BRPPG has good CO2 phase stability at 65 °C, and no dehydration was observed after 60 days of exposure to 2900 psi CO2 at 65 °C. Core flooding test proved that the swelled particles could reform a bulk gel after being placed in the fractures, and the reformed bulky gel has excellent CO2 plugging efficiency. The supercritical CO2 breakthrough pressure gradient was 265 psi/feet (5.48 MPa/m). This work could offer the experimental basis for the field application of this CO2-BRPPG in CO2 storage and CO2 enhanced oil recovery

Simultaneously Enhancing the Flame Retardancy, Water Resistance, and Mechanical Properties of Flame-Retardant Polypropylene via a Linear Vinyl Polysiloxane-Coated Ammonium Polyphosphate

It is challenging to improve the water resistance, flame retardancy, mechanical performance, and balance of halogen-free flame-retardant polypropylene (PP) composites. For this purpose, a linear vinyl polysiloxane (PD) was synthesized and then self-crosslinked under benzoyl peroxide to prepare surface-coated ammonium polyphosphate (APP@PD). Apparently, this linear vinyl polysiloxane self-crosslinking coating strategy was completely different from the commonly used sol-gel-coated APP with silane monomers. After coating, the water contact angles (WCA) of APP and APP@PD were 26.8° and 111.7°, respectively, showing high hydrophobicity. More importantly, PP/APP@PD/dipentaerythritol (DPER) showed a higher limiting oxygen index (LOI) and better UL-94 V-0 rate in comparison with PP/APP/DPER composites. After water immersion at 70 °C for 168 h, only PP/APP@PD/DPER kept the UL-94 V-0 rate and lowered the deterioration of the LOI, reflecting the better water-resistance property of APP@PD. Consistently, the cone calorimeter test results displayed a 26.2% and 16.7% reduction in peak heat release rate (PHRR) and total smoke production (TSP), respectively. Meanwhile, the time to peak smoke production rate (TPSPR) increased by 90.2%. The interfacial free energy (IFE) between APP@PD and PP was calculated to evaluate the interfacial interaction between PP and APP@PD. A reduction of 84.2% in the IFE between APP@PD and PP is responsible for the improvement in compatibility and the increase in flame retardancy, water resistance, and mechanical properties of the composites

Investigation of Matrix Damage and Remediation Methods of Preformed Particle Gel Conformance Control Treatments in Carbonate Reservoirs

Preformed Particle Gels (PPGs) have been widely applied to control excessive water production in mature oil fields with fractures or fracture-like features, especially in sandstones, but with limited attention to carbonates. However, a vital concern arises regarding the potential damage of PPGs on the adjacent matrix that might promote negative results. This paper comprehensively evaluates PPGs\u27 potential damage to the carbonate matrix and seeks design optimization solutions. Filtration tests were applied to compare PPGs\u27 penetration into matrix under different sets of conditions. The filtration regimes were defined by filtration curves and the gel damage on matrix was determined by permeability measurement results. Experiments were conducted to investigate the efficiency of an oxidizer as a remediation method to remove the damage. The qualitative description of gel particles\u27 invasion and plugging behavior in the carbonate matrix was presented based on the analysis of filtration test results and permeability measurements. Results show that the swollen gel filtration curves can be divided into three regions: prior-filter-cake, filter-cake-building, and stable stages according to the gel particles\u27 response to the injection pressure and effluent flow rates. PPGs can form cakes on the rock surface to prevent particles\u27 further penetration into carbonate matrix, and the penetration was only limited to less than a few millimeters. The smallest gel particles (50-70 US mesh size) were more likely to form external and internal filter cakes at higher pressure values (700 psi) and result in more damage to the matrix. To restore the matrix permeability after filtration tests, oxidizer soaking was proved to be a reliable solution. In all, the results indicated that unintentional matrix permeability damage induced by gel injection is generally unavoidable, but conditionally treatable

Investigation of Matrix Damage and Remediation Methods of Preformed Particle Gel Conformance Control Treatments in Carbonate Reservoirs

Preformed Particle Gels (PPGs) have been widely applied to control excessive water production in mature oil fields with fractures or fracture-like features, especially in sandstones, but with limited attention to carbonates. However, a vital concern arises regarding the potential damage of PPGs on the adjacent matrix that might promote negative results. This paper comprehensively evaluates PPGs' potential damage to the carbonate matrix and seeks design optimization solutions. Filtration tests were applied to compare PPGs' penetration into matrix under different sets of conditions. The filtration regimes were defined by filtration curves and the gel damage on matrix was determined by permeability measurement results. Experiments were conducted to investigate the efficiency of an oxidizer as a remediation method to remove the damage. The qualitative description of gel particles' invasion and plugging behavior in the carbonate matrix was presented based on the analysis of filtration test results and permeability measurements. Results show that the swollen gel filtration curves can be divided into three regions: prior-filter-cake, filter-cake-building, and stable stages according to the gel particles' response to the injection pressure and effluent flow rates. PPGs can form cakes on the rock surface to prevent particles' further penetration into carbonate matrix, and the penetration was only limited to less than a few millimeters. The smallest gel particles (50-70 US mesh size) were more likely to form external and internal filter cakes at higher pressure values (700 psi) and result in more damage to the matrix. To restore the matrix permeability after filtration tests, oxidizer soaking was proved to be a reliable solution. In all, the results indicated that unintentional matrix permeability damage induced by gel injection is generally unavoidable, but conditionally treatable. Copyright 2022, Society of Petroleum Engineers.The authors would like to acknowledge the Qatar National Research Fund (a member of Qatar Foundation) for funding through Grant # NPRP13S-1231-190009. Al-Salam Petroleum Services Company, Qatar, is also acknowledged for co-funding this project. The findings achieved herein are solely the responsibility of the authors.Scopu

A Comprehensive Review of Experimental Evaluation Methods and Results of Polymer Micro/nanogels for Enhanced Oil Recovery and Reduced Water Production

In recent years, polymer micro/nanogels which are re-crosslinked polymers with 3D networks, have attracted a lot of interest in Enhanced Oil Recovery (EOR) field. In size of micro/nanometers, these gel particles are designed to be conformance control agents for in-depth fluid diversion, and various experimental research have been undertaken to investigate the possibilities of applying micro/nanogels in oilfield. However, it is still unclear that how to utilize micro/nanogels to their full potential in oilfield because the transport mechanisms and EOR mechanisms of micro/nanogels are not well studied currently. By reviewing experimental evaluations and corresponding results of micro/nanogels, including evaluation of particle physiochemical properties, transport, and potential EOR mechanisms, the review aims to discuss the evaluation of micro/nanogel particles, transport issue in many experimental designs and the debates of EOR mechanisms. Finally, we present the current challenges of micro/nanogels application and recommend the future research directions based on the review

Direct Pore-Level Visualization and Verification of In Situ Oil-in-Water Pickering Emulsification during Polymeric Nanogel Flooding for EOR in a Transparent Three-Dimensional Micromodel

Different from inorganic nanoparticles, nanosized cross-linked polymeric nanoparticles (nanogels) have been demonstrated to generate more stable Pickering emulsions under harsh conditions for a long term owing to their inherent high hydrophilicity and surface energy. In both core and pore scales, the emulsions are found to be able to form in situ during the nanofluid flooding process for an enhanced oil recovery (EOR) process. Due to the limitation of direct visualization in core scale or deficient pore geometries built by two-dimensional micromodels, the in situ emulsification by nanofluids and emulsion transport are still not being well understood. In this work, we use a three-dimensional transparent porous medium to directly visualize the in situ emulsification during the nanogel flooding process for EOR after water flooding. By synthesizing the nanogel with a fluorescent dye, we find the nanogels adsorbed on the oil-water interface to lower the total interfacial energy and emulsify the large oil droplets into small Pickering oil-in-water emulsions. A potential mechanism for in situ emulsification by nanogels is proposed and discussed. After nanogel flooding, the emulsions trapped in pore throats and those in the effluents are all found encapsulated by the nanogels. After nanogel flooding under different flow rates, the sphericity and diameter changes of remaining oil droplets are quantitatively compared and analyzed using grouped boxplots. It is concluded that in situ emulsification happens during nanogel injection due to the reduction of interfacial tension, which helps to increase the oil recovery rate under different flow rates and pore geometries

Kinetics And Equilibrium Of Nanogel Adsorption And Desorption On Sandstone

Polymer nanogels, elastic nanospheres with 3D network structure, have been recognized as promising materials to enhance oil recovery because they are designed to transport in deep of reservoirs for in-depth fluid diversion. Although conventional hard nanoparticles have been intensively investigated, the dynamic adsorption and desorption of elastic polymer nanospheres in porous media are still unclear, causing the uncertainty of applying them in the deep of reservoirs. In this work, we conducted circulation flowing experiments and post water flooding experiments to investigate the dynamic adsorption and desorption of nanogel in sandstones. Through UV–vis spectrophotometer, we found that nanogel exhibited rapid adsorption and desorption at the initial stages, but they have a long tail to reach equilibrium, in which the adsorption density distributed from 0.083 to 0.435 mg/g. The adsorption of nanogel increased with their concentration and core permeability, as well as salt concentration. However, salinity played a more important role during the desorption process due to the strong interaction between nanogel and sandstones. We also calculated the adsorption layer thickness, which ranges from 0.67 to 2.14, the results suggested that most of nanogel adsorption are multilayered processes. And the adsorption kinetics were fit by empirical equations, including pseudo-first order and pseudo-second order. The fitting comparison showed that the pseudo-first-order model is better suited for extreme low or high salinity (0.05% and 10% NaCl), while the pseudo-second-order model is preferred for moderate salinity (1% NaCl). These findings provide valuable insights for the effective placement of nanogel in oil recovery processes